Development of hybrid low salinity water polymer flooding numerical reservoir simulator and smart proxy model for chemical enhanced oil recovery (CEOR)

Brantson, Eric Thompson; Ju, Binshan; Appau, Prince Opoku; Akwensi, Perpetual Hope; Peprah, Godwill Agyare; Liu, Nannan; Aphu, Elvis Selase; Boah, Evans Annan; Borsah, Abraham Aidoo

doi:10.1016/j.petrol.2019.106751

Cited by 31 publications

(19 citation statements)

References 24 publications

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“…The salinity of the injection water was however overlooked. 5 Flooding with low salinity water has been shown in studies to improve oil recovery. 6 Seecombe 7 tested the efficacy of low salinity waterflooding over long inter-well distances in the field.…”

Section: Trends In Petroleum Engineeringmentioning

confidence: 99%

“…In an effort to enhance recovery from hydrocarbon reserves, chemically enhanced oil recovery techniques have been looked into. 5 These techniques involve injecting chemicals into the reservoir to boost oil recovery. These chemicals enhance recovery by decreasing the Interfacial Tension (IFT) between the imbibing fluid and the oil, altering the fluid viscosity to improve mobility and conformance control, and altering the wettability of the rock, to increase the oil relative permeability.…”

Section: Trends In Petroleum Engineeringmentioning

confidence: 99%

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Numerical Simulation of Low Salinity Water and Alkaline Surfactant-Polymer Flooding with Optimal Injection Pattern

Brantson¹

2023

TPE

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Combined Low Salinity Water (LSW) and Alkaline-Surfactant-Polymer (ASP) flooding is a new enhanced oil recovery method that aids oil recovery from reservoirs following the traditional recovery methods. Experimental studies on combined LSW and ASP flooding show additional oil recovery potential. This paper used numerical simulation to investigate different flooding patterns with LSW and ASP combined. A homogenous reservoir was saturated with oil and water to obtain the required modelled factors. Oil reservoir simulations of 11 flooding patterns were created and run using ECLIPSE 100. These patterns were used in the field's development for five years. The results showed the normal 7-spot pattern to provide the best recovery, while the direct line drive provided the worst. The high salinity, low salinity, and combined LSW and ASP flooding recorded oil recoveries of 30%, 55%, and 93%, respectively. An economic analysis was also done to analyse the project’s economic viability which proved to be economical with a profit margin of 40.7%. Furthermore, it was discovered that normal flood patterns outperformed their inverted counterparts. It was thus concluded that the normal 7-spot pattern provides the highest profits from a purely technical standpoint.

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Section: Trends In Petroleum Engineeringmentioning

confidence: 99%

Section: Trends In Petroleum Engineeringmentioning

confidence: 99%

Numerical Simulation of Low Salinity Water and Alkaline Surfactant-Polymer Flooding with Optimal Injection Pattern

Brantson¹

2023

TPE

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“…Numerous methods fall within EOR, such as chemical flooding, microbial recovery, gas injection, and thermal recovery (Figure ). − The ultimate aim of EOR is to improve overall oil recovery by improving the microscopic and macroscopic oil displacement efficiencies. These improvements can be achieved by influencing the properties of the rocks and fluids, such as oil viscosity, rock wettability, oil–water interfacial tension (IFT), and capillary pressure, to improve the mobility ratio between the displacing and displaced fluids. ,,− Data published by the International Energy Agency (IEA) and cited by Kalam et al show the global count of EOR projects between 1971 and 2017, revealing varying trends in the number of EOR projects corresponding to the different EOR methods.…”

Section: Introductionmentioning

confidence: 99%

Oil Recovery Performance by Surfactant Flooding: A Perspective on Multiscale Evaluation Methods

et al. 2022

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Chemical-enhanced oil recovery (cEOR) is a class of techniques commonly used to extract hydrocarbon fluids from reservoir rocks beyond conventional waterflooding. Surfactants are among the chemical agents employed in a cEOR process, as they aid in enhancing oil recovery by lowering the oil–water interfacial tension (IFT) and altering the rock wettability toward less oil-wet conditions. Understanding the flow characteristics and mechanisms involved during surfactant flooding helps improve the performance of injected surfactants and results in higher oil recovery. The objective of this review is to outline the recent applications of the different methods employed to understand the behavior and mechanisms involved during surfactant-enhanced oil recovery. The review begins with a general background highlighting the basic characteristics of surfactants and the main mechanisms by which they exert their influence. Recent studies conducted to investigate the oil recovery performance through different methods are then presented, including traditional coreflooding experiments, microfluidics studies, and oil recovery through sand packs. The methodology of the analysis and the interpretation of the data obtained from the different oil recovery tests, including oil recovery factor, pressure data, and relative permeability, are also described. Pore-scale analysis and imaging methods including nuclear magnetic resonance (NMR), magnetic resonance imaging (MRI), and X-ray medical and microcomputed tomography (μCT) scanning and their applicability in assessing the recovery performance are described. Finally, a few examples of field monitoring methods for surfactant flooding are highlighted. This review provides knowledge of the different multiscale evaluation methods and their applicability during surfactant flooding.

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“…Consequently, most oil fields introduce chemical reagents to lower the permeability of the high-permeability layer and enhance the oil displacement efficiency to increase the oil recovery . Polymer flooding, as a representative EOR technique, is extensively employed in many oilfields, owing to its wide range of material sources, easy synthetic methods, high oil displacement efficiency, and low cost. , Following injection, the polymer can selectively seal the high-permeability zone and lower its permeability. At a constant injection rate, the injection pressure increases throughout the well, increasing the adsorption differential pressure and liquid absorption volume in the medium- and low-permeability zones.…”

Section: Introductionmentioning

confidence: 99%

Mechanistic Study on the Decrease in Injectivity during Salt-Resistant Polymer Flooding

et al. 2022

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According to numerous laboratory experiments and field applications, polymer flooding can effectively modify the liquid absorption profile and increase the sweep efficiency, thereby enhancing the oil recovery. However, long-term injection of polymers decreases the effective permeability of the reservoir and plugs the formation pores, resulting in irreversible reservoir damage. In the development process, polymer types and concentrations must be selected according to the reservoir to avoid problems such as plugging of the formation pores. This study was aimed at clarifying the degree of plugging and the injection limit of the reservoir when a salt-resistant polymer (SRP) is used in production processes of the Daqing Oilfield. To this end, oil displacement experiments, dynamic and static adsorption experiments, and SEM observations were performed using representative reservoir fluid and core samples. The static adsorption of “medium-molecular” SRP reached equilibrium after 36 h, and the saturated adsorption capacity was 3.56 mg/g, which was approximately 2–5 times the dynamic adsorption capacity. For medium-molecular SRP, with a molecular mass of 7 million, the lower limit of the core permeability was 20–40 mD. When the permeability was less than 100 mD, the SRP concentration injected into the core could not exceed 900 mg/L. The oil displacement capacity of SRP decreased owing to the macromolecular hydration radius and the strong aggregation effect of SRP. Polymer adsorption and the retention of sand-carrying critically decreased water permeability. This study provides insights into SRP flooding under different geological conditions in the Daqing Oilfield and can help clarify the molecular mass and concentration of polymers with changes in the reservoir conditions.

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Development of hybrid low salinity water polymer flooding numerical reservoir simulator and smart proxy model for chemical enhanced oil recovery (CEOR)

Cited by 31 publications

References 24 publications

Numerical Simulation of Low Salinity Water and Alkaline Surfactant-Polymer Flooding with Optimal Injection Pattern

Numerical Simulation of Low Salinity Water and Alkaline Surfactant-Polymer Flooding with Optimal Injection Pattern

Oil Recovery Performance by Surfactant Flooding: A Perspective on Multiscale Evaluation Methods

Mechanistic Study on the Decrease in Injectivity during Salt-Resistant Polymer Flooding

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